EP0465161A1 - Méthode pour contrôler la température, productions et sélectivité dans un appareillage et procédé de conversion et de craquage d'hydrocarbures en lit fluidisé - Google Patents

Méthode pour contrôler la température, productions et sélectivité dans un appareillage et procédé de conversion et de craquage d'hydrocarbures en lit fluidisé Download PDF

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Publication number
EP0465161A1
EP0465161A1 EP91305883A EP91305883A EP0465161A1 EP 0465161 A1 EP0465161 A1 EP 0465161A1 EP 91305883 A EP91305883 A EP 91305883A EP 91305883 A EP91305883 A EP 91305883A EP 0465161 A1 EP0465161 A1 EP 0465161A1
Authority
EP
European Patent Office
Prior art keywords
feed
atomization
reactor
injector
nozzle
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Granted
Application number
EP91305883A
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German (de)
English (en)
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EP0465161B1 (fr
Inventor
Craig Young Sabottke
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
ExxonMobil Technology and Engineering Co
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Exxon Research and Engineering Co
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Filing date
Publication date
Priority claimed from US07/548,476 external-priority patent/US5188805A/en
Application filed by Exxon Research and Engineering Co filed Critical Exxon Research and Engineering Co
Publication of EP0465161A1 publication Critical patent/EP0465161A1/fr
Application granted granted Critical
Publication of EP0465161B1 publication Critical patent/EP0465161B1/fr
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    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G11/00—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C10G11/14—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts
    • C10G11/18—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised-bed" technique
    • C10G11/187—Controlling or regulating
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J8/00—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes
    • B01J8/18—Chemical or physical processes in general, conducted in the presence of fluids and solid particles; Apparatus for such processes with fluidised particles
    • B01J8/1809—Controlling processes

Definitions

  • gases formed during regeneration/gasification of the spent solid particles can pass from the dense phase fluid bed 24B into the dilute phase 24C along with entrained solid particles.
  • the solid particles are separated from the gas by a suitable gas-solid separation means 32 and returned to the dense phase fluid bed 24B.
  • the substantially solid particle-free gas then passes into a plenum chamber 34 prior to discharge from the regenerator/heater 12 into down stream gas handling equipment through line 60.
  • FIG. 2A shows the reaction portion of the fluid coking and gasification unit in isolation from the heater and gasifier portion and in conjunction with certain process control instrumentation and signals.
  • the control system and equipment are in itself conventional, as will be readily appreciated by those skilled in the art and, therefore, are shown only schematically.
  • the numbers in FIG. 2 which are less than or equal to 52 are the same as the numbers in FIG. 1 and correspond to the same parts.
  • a feed injector nozzle atomization adjustment assembly comprising a shaft 105 and a lead portion or adjusting means 106, is shown in greater detail in FIG. 4.
  • An end tip portion 108 of this adjusting means 106 is designed to function within the converging fan tip nozzle 102. Modulation and/or positioning of the end tip portion 108 within the nozzle tip 102 will change the flow area and influence the atomization achieved by the nozzle tip 102.
  • a preferred addition to the basic design of the variable atomization adjustment means feed injector is to include premixers 107 and 109 in close proximity to the nozzle insert tip 106. The premixers enhance the atomization, particularly the spray pattern, achieved by the variable atomization adjustment means feed injector.
  • the embodiment of a reactor feed injector assembly shown in FIG. 3 represents a minimum stroke design.
  • the steam/oil ratio will be set based on oil properties and other process considerations.
  • the oil phase may be partially vaporized as a result of preheating.
  • the fluid mixture being supplied to the feed injector assembly will usually consist of a gas phase, a liquid oil phase and possibly a vapor oil phase.
  • an isolation valve 115 between flanges 116 and 118 may be used as part of the feed injector assembly to allow for onstream maintenance of the system.
  • This isolation valve is usually a gate valve, although other valve types such as a ball valve may be used.
  • the atomization adjusting means assembly for the nozzle can be retracted, the isolation valve closed and the assembly removed as required for on-stream maintenance. For example, if feed type and chemistry should cause undesirable coking or partial plugging of the nozzle inside, the nozzle insert shaft assembly can be removed and subjected to onstream cleaning.
  • a suitable mechanical positioning means is exemplified by actuator assembly 221, which provides for the mechanical movement, modulation and stroke control of the nozzle atomization adjustment assembly and shaft. Control of the relative position of the nozzle atomization adjustment assembly relative to the nozzle tip 102 influences the atomization and/or spray pattern from the nozzle.
  • actuator assembly 221 which provides for the mechanical movement, modulation and stroke control of the nozzle atomization adjustment assembly and shaft. Control of the relative position of the nozzle atomization adjustment assembly relative to the nozzle tip 102 influences the atomization and/or spray pattern from the nozzle.
  • a pneumatic actuator with a manual override feature hand wheel operator
  • Other actuator configurations are also acceptable, including a hydraulic actuator or motor-driven actuator. The actuator is capable of receiving control instructions from other instruments and controllers and moving the position of the atomization adjusting means based on these control instructions.
  • FIGS. 8A and 8B show in detail an installation of a typical feed injector attached to the wall of either a reactor riser (FIG. 8A) or the reactor fluid bed portion of the reactor (FIG. 8B).
  • the nozzle tip portion 110 is shown positioned at a typical angle of 20 degrees to the vertical.
  • the feed injector is shown in cross-section transversing a conical segment shaped wall 230 section which itself is at a 30 degree angle from the vertical, between an upper relatively larger diameter cylindrical vertical wall portion 232 and a lower relatively smaller diameter cylindrical vertical wall portion 234 of the riser. Different attachment angles and orientation angles may be used depending on the specific unit and type of injector.
  • Kim and Marshall drop-size correlations for convergent-type pneumatic nozzles were obtained for the following ranges: drop-size, 6 to 350 ⁇ m mass medium diameter; mass flow ratio, 0.06 to 40; relative velocity, 250 ft/sec to sonic velocity, and viscosity 1 to 50 cp.
  • X ⁇ ⁇ s 0.83 X ⁇ m
  • X ⁇ m Mass medium diameter
  • ⁇ m X ⁇ ⁇ s sauter mean diameter
  • ⁇ m ⁇ Surface tension
  • dynes/ ⁇ m ⁇ 1 Liquid viscosity
  • cp ⁇ a , ⁇ 1 Gas and liquid densities
  • lb/ft3 A Area
  • ft2 v rel Gas to liquid relative velocity
  • ft/sec M a ,M1 Gas to liquid mass flowrates, lbs/min
  • the function of the transmitter is to project two coherent laser beams into a chosen test space where they may be moving droplets.
  • the droplets scatter light from the fringe pattern caused by the crossing beams and the frequency and modulation yield the velocity and size of the measured droplets.
  • the "permanent" alignments, which require more care, need only be touched very rarely, if at all.
  • the transmitter contains a Spectra-Physics Model Number 107 DEM Helium Neon Laser, laser power supply, steering mirrors, a telescopic beam expander, a half wave plate, a beam steering prism, a 50% beamsplitter and interchangeable output optics.
  • the receiver is essentially a telescope with a photomultiplier to collect light from the focal point, at which there is an interchangeable pinhole.
  • the positioning of the entire assembly is so as to align it approximately with the transmitted probe volume.
  • the receiver collects light that has been scattered from anything within the illuminated sample volume and directs it on to the cathode of the photomultiplier.
  • the distribution of drop sizes with nozzle no. 3 appear to be wide and bimodal.
  • a complete first mode and part of the second mode were recorded in the sprays when the liquid flow rate was lowest at 10 gpm as in Runs 11 and 16.
  • the base case liquid rate scaled down from a commercial FCCU is 20 gpm. This indicates that spray drop size can be reduced by lowering the liquid feed rate in the commercial FCCU when using a fan nozzle. Higher liquid viscosity gave larger drops as indicated by the drop size data with 1.3 cp (Runs 7, 8, 11) and 2.6 cp (Runs 12, 13, 16) liquids.
  • the effect of liquid viscosity on ⁇ P was not noticeable in the narrow viscosity range of 1.3 to 2.6 cp.
  • variable XTONAREA is the total nozzle flow area, sq. ft. Individual position of the nozzle insert in each nozzle will allow the flow area in the throat to be calculated for the nozzle geometry. The total flow area available is then calculated based on the number of active nozzles in service.
  • CF ((B o * 2 * X2021 * X2026 * X2025)/P2099avg) ** 0.5 where A o and B o are constants which must be determined empirically for each particular nozzle design.
  • a reactor temperature control operating mode will now be described, using the information provided above.
  • a process controller designated T-2001RC, will reset individual feed injector nozzle controllers to open or close the available flow area to allow more or less total feed to pass into the reactor.
  • the flow coefficient parameter "CF" will be monitored in a fashion to ensure that a good atomization region is being maintained for the majority of the feed injectors.
  • Selected injectors will be manipulated by T-2001RC to influence the process carbon and heat balance and maintain a desired reactor temperature as process conditions change.
  • the primary parameter being controlled in this control scheme is the reactor coke yield and the heat required by the reaction system for the conversion and cracking reactions.
  • the control computer calculated flow coefficient is used as an index to manipulate the process carbon and heat balance, to achieve the target reactor temperature.
  • the process feed injector pressure drop reading is a gross indication of feed injector atomization. ( at a constant flow rate through the injectors), but many process factors can and will influence this reading.
  • CF flow coefficient
  • a more representative indication of feed atomization is obtained. This allows flexibility for more intelligent control decisions and hierarchy to be applied to the fluid coking with gasification process to achieve target operating objectives. Also, control of the feed injector atomization can achieve a much more precise control compared to throttling large solid particle flows through a slide valve or manipulation of feed preheat duty.
  • the 20% of the total number of feed injector nozzles used in this example may be ramped open or closed by moving opposing pairs of nozzles as a unit.
  • the pairings would typically be as follows: A/F, B/G, C/H, D/I, and E/J for a reactor system with a total of ten feed injector nozzles).
  • each pair of injectors would be moved a maximum of about 10% stroke at a time in response to feed rate changes. This 10% increment corresponds to about 2.7% of the total nozzle throat area being manipulated at one time.
  • Table 5 below illustrates a typical sequential flow area change using this technique:
  • Table 5 above illustrates how a very precise flow area control can be maintained and manipulated to achieve the desired level of feed atomization.
  • the above case is an illustration of a controlled ramping closed of the feed injectors, caused by a change/deviation in T-2001RC from its set point. To ramp open the feed injector flow area a reverse sequence would be used.
  • the control computer application program could be constructed in several different forms.
  • the reactor temperature controller, T-2001RC could be cascaded directly to the feed injector actuators, H-2099-1C (A to J), or in a layered hierarchy with F-2004-RC cascaded to P-2099-dRC (A to J) which in turn could be cascaded to the individual feed injector actuators, H-2099-1C (A to J).
  • Having individual actuator controllers and PdRC instrumentation on each feed injector provides flexibility for on stream maintenance and control loop tuning of the feed injector system. Lower cost configurations are possible with fewer instruments, and would represent a simplified version of the configuration detailed above.
  • FIG. 10 (parts A and B) is a schematic illustrating the basic structure of a typical control computer application program to vary feed injector throat area based on reactor temperature control requirements as indicated by the T-2001RC controllers. It is based on a reference ten variable atomization means feed injector system with a PdRC controller cascaded to the injector actuator, HIC: P-2099-dRC A cascaded to H-2099-1C A,etc.
  • the reactor temperature controller T-2001RC will generate controller signals in response to changes in the target set point.
  • T-2001RC is cascaded to 20% of the total feed injectors.
  • Console operator-supplied set points for P-2099-dRC (A to J) are based on a unit specific run plan to initialize the system. This set point is consistent with a target spray pattern/ degree of atomization.
  • the calculated flow coefficient "CF" will be calculated in a real time frame. This "CF" will be used as an index of feed atomization.

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  • Chemical & Material Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Organic Chemistry (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Combustion & Propulsion (AREA)
  • General Chemical & Material Sciences (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
EP19910305883 1990-07-03 1991-06-28 Méthode pour contrÔler la température, productions et sélectivité dans un appareillage et procédé de conversion et de craquage d'hydrocarbures en lit fluidisé Expired - Lifetime EP0465161B1 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US548473 1983-11-03
US548476 1983-11-03
US54847390A 1990-07-03 1990-07-03
US07/548,476 US5188805A (en) 1990-07-03 1990-07-03 Controlling temperature in a fluid hydrocarbon conversion and cracking apparatus and process comprising a novel feed injection system

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EP0465161A1 true EP0465161A1 (fr) 1992-01-08
EP0465161B1 EP0465161B1 (fr) 1999-08-04

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JP (1) JPH04226590A (fr)
CA (1) CA2044074C (fr)
DE (1) DE69131498D1 (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2576733A1 (fr) * 2010-05-24 2013-04-10 Saudi Arabian Oil Company Commande de procédé de craquage catalytique fluide permettant de réduire l'utilisation d'additifs pour la désulfuration de charges de pétrole
US10654033B2 (en) 2015-11-24 2020-05-19 Uop Llc Vertical separation vessel for ionic liquid catalyzed effluent

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US9701914B2 (en) * 2006-11-07 2017-07-11 Saudi Arabian Oil Company Advanced control of severe fluid catalytic cracking process for maximizing propylene production from petroleum feedstock
CN112760136B (zh) * 2019-09-16 2022-02-18 中国科学院工程热物理研究所 循环流化床气化装置和循环流化床气化方法

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4434049A (en) * 1982-03-17 1984-02-28 Dean Robert R Residual oil feed process for fluid catalyst cracking
US4575414A (en) * 1984-08-29 1986-03-11 Phillips Petroleum Company Method for mixing of fluidized solids and fluids
EP0208609A1 (fr) * 1985-07-10 1987-01-14 Total Raffinage Distribution S.A. Procédé et dispositif pour le craquage catalytique de charges d'hydrocarbures, avec contrôle de la température de réaction
EP0227864A1 (fr) * 1984-05-30 1987-07-08 Mobil Oil Corporation Appareillage d'injection de la charge dans un FCC et procédé FCC
US4793913A (en) * 1983-02-04 1988-12-27 Chevron Research Company Method for liquid feed dispersion in fluid catalytic cracking systems
EP0444859A1 (fr) * 1990-02-27 1991-09-04 Exxon Research And Engineering Company Procédé et dispositif pour contrôler une unité de craquage catalytique fluidisé

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4434049A (en) * 1982-03-17 1984-02-28 Dean Robert R Residual oil feed process for fluid catalyst cracking
US4793913A (en) * 1983-02-04 1988-12-27 Chevron Research Company Method for liquid feed dispersion in fluid catalytic cracking systems
EP0227864A1 (fr) * 1984-05-30 1987-07-08 Mobil Oil Corporation Appareillage d'injection de la charge dans un FCC et procédé FCC
US4575414A (en) * 1984-08-29 1986-03-11 Phillips Petroleum Company Method for mixing of fluidized solids and fluids
EP0208609A1 (fr) * 1985-07-10 1987-01-14 Total Raffinage Distribution S.A. Procédé et dispositif pour le craquage catalytique de charges d'hydrocarbures, avec contrôle de la température de réaction
EP0444859A1 (fr) * 1990-02-27 1991-09-04 Exxon Research And Engineering Company Procédé et dispositif pour contrôler une unité de craquage catalytique fluidisé

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2576733A1 (fr) * 2010-05-24 2013-04-10 Saudi Arabian Oil Company Commande de procédé de craquage catalytique fluide permettant de réduire l'utilisation d'additifs pour la désulfuration de charges de pétrole
EP2576733A4 (fr) * 2010-05-24 2014-02-26 Saudi Arabian Oil Co Commande de procédé de craquage catalytique fluide permettant de réduire l'utilisation d'additifs pour la désulfuration de charges de pétrole
US10654033B2 (en) 2015-11-24 2020-05-19 Uop Llc Vertical separation vessel for ionic liquid catalyzed effluent

Also Published As

Publication number Publication date
CA2044074A1 (fr) 1992-01-04
EP0465161B1 (fr) 1999-08-04
DE69131498D1 (de) 1999-09-09
CA2044074C (fr) 2003-01-21
JPH04226590A (ja) 1992-08-17

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